Production of renewable biofuels

ABSTRACT

Renewable fuels are produced in commercial quantities and with enhanced efficiency by integrating a bio-oil production system with a conventional petroleum refinery so that the bio-oil is co-processed with a petroleum-derived stream in the refinery. The techniques used to integrate the bio-oil production system and conventional petroleum refineries are selected based on the quality of the bio-oil and the desired product slate from the refinery.

RELATED APPLICATIONS

This application is a divisional application of U.S. patent applicationSer. No. 13/339,811, filed Dec. 29, 2011, which claims priority to U.S.Provisional Patent Application Ser. No. 61/428,613, filed Dec. 30, 2010.

BACKGROUND

1. Field of the Invention

The present invention relates generally to the production of renewablefuels. More specifically, the invention concerns the integration of abiomass conversion facility with a conventional refinery to efficientlyproduce commercial quantities of renewable fuels.

2. Description of the Related Art

With the rising costs and environmental concerns associated with fossilfuels, renewable energy sources have become increasingly important. Thedevelopment of renewable fuel sources provides a means for reducing thedependence on fossil fuels. Accordingly, many different areas ofrenewable fuel research are currently being explored and developed.

With its low cost and wide availability, biomass has increasingly beenemphasized as an ideal feedstock in renewable fuel research.Consequently, many different conversion processes have been developedthat use biomass as a feedstock to produce useful biofuels and/orspecialty chemicals. Existing biomass conversion processes include, forexample, combustion, gasification, slow pyrolysis, fast pyrolysis,liquefaction, and enzymatic conversion. One of the useful products thatmay be derived from the aforementioned biomass conversion processes is aliquid product commonly referred to as “bio-oil.” Bio-oil may beprocessed into transportation fuels, hydrocarbon chemicals, and/orspecialty chemicals.

Despite recent advancements in biomass conversion processes, many of theexisting biomass conversion processes produce low-quality bio-oils thatare highly unstable and often contain high amounts of oxygen. Thesebio-oils require extensive secondary upgrading in order to be utilizedas transportation fuels and/or as fuel additives due their instability.Furthermore, the transportation fuels and/or fuel additives derived frombio-oil vary in quality depending on factors affecting the stability ofthe bio-oil, such as the original oxygen content of the bio-oil.

Bio-oils can be subjected to various upgrading processes in order toprocess the bio-oil into renewable fuels and/or fuel additives. However,prior upgrading processes have been relatively inefficient and producerenewable fuels and/or fuel additives that have limited use in today'smarket. Furthermore, only limited amounts of these bio-oil derivedtransportation fuels and/or fuel additives may be combinable withpetroleum-derived gasoline or diesel.

Accordingly, there is a need for an improved process and system forusing bio-oil to produce renewable fuels.

SUMMARY OF THE INVENTION

In one embodiment, the present invention is directed to a process forproducing a renewable fuel, where the process comprises the steps of (a)providing one or more bio-oils selected from the group consisting of ahigh-stability bio-oil, an intermediate-stability bio-oil, and alow-stability bio-oil, wherein the high-stability bio-oil has astability parameter of less than 30 centipoise per hour (cp/h), theintermediate-stability bio-oil has a stability parameter in the range of30 to 75 cp/h, and the low-stability bio-oil has a stability parametergreater than 75 cp/h; and (b) processing at least one of the bio-oils ina petroleum refinery according to one or more of the following methods:(i) combining at least a portion of the high-stability bio-oil with afirst petroleum-derived stream of the petroleum refinery to thereby forma first combined stream, hydrotreating the first combined stream tothereby produce a first hydrotreated stream, and fractionating the firsthydrotreated stream; (ii) combining at least a portion of thehigh-stability bio-oil with a second petroleum-derived stream of thepetroleum refinery to thereby form a second combined stream,catalytically cracking the second combined stream to thereby produce asecond cracked stream, and fractionating the second cracked stream;(iii) combining at least a portion of the intermediate-stability bio-oilwith a third petroleum-derived stream of the petroleum refinery tothereby form a third combined stream, hydrotreating the third combinedstream to thereby produce a third hydrotreated stream, catalyticallycracking at least a portion of the third hydrotreated stream to therebyproduce a third cracked stream, and fractionating the third crackedstream; (iv) combining at least a portion of the intermediate-stabilitybio-oil with a fourth petroleum-derived stream of the petroleum refineryto thereby form a fourth combined stream, hydrotreating the fourthcombined stream to thereby produce a fourth hydrotreated stream,thermally cracking at least a portion of the fourth hydrotreated streamto thereby produce a fourth cracked stream, and fractionating the fourthcracked stream; (v) combining at least a portion of the low-stabilitybio-oil with a fifth petroleum-derived stream of the petroleum refineryto thereby form a fifth combined stream, thermally cracking at least aportion of the fifth combined stream to thereby produce a fifth crackedstream, and fractionating the fifth cracked stream; and/or (vi)combining at least a portion the low-stability bio-oil with a sixthpetroleum-derived stream of the petroleum refinery to thereby form asixth combined stream, fractionating at least a portion of the sixthcombined stream into at least a sixth heavy bio-fraction and a sixthlight bio-fraction, hydrotreating at least a portion of the sixth lightbio-fraction to thereby produce a sixth hydrotreated bio-fraction, andthermally cracking at least a portion of the sixth heavy bio-fraction tothereby produce a sixth thermally cracked bio-fraction.

In another embodiment, the present invention is directed to a system forproducing renewable fuels, where the system comprises (a) a bio-oilproduction facility comprising a biomass conversion reactor forconverting biomass into bio-oil; (b) a petroleum refinery for refiningpetroleum products; and (c) an integration system for optionallycombining at least a portion of the bio-oil from the bio-oil productionfacility with one or more petroleum-derived streams in the petroleumrefinery for co-processing therewith. In another embodiment, the bio-oilcan be co-processed with one or more petroleum-derived streams withoutfirst combining the two streams (i.e. charging each stream to theconversion unit as a separate feed). The integration system comprises atleast one of a first, second, third, fourth, fifth, and/or sixthintegration mechanism for combining at least a portion of the bio-oilwith at least one of the petroleum-derived streams. The refinerycomprises one or more of the following refining systems: (i) a firsthydrotreating unit and a first fractionator, wherein the firsthydrotreating unit is located downstream of the first integrationmechanism and the first fractionator is located downstream of the firsthydrotreating unit; (ii) a second catalytic cracking unit and a secondfractionator, wherein the second catalytic cracking unit is locateddownstream of the second integration mechanism and the secondfractionator is located downstream of the second catalytic crackingunit; (iii) a third hydrotreating unit, a third catalytic cracking unit,and a third fractionator, wherein the third hydrotreating unit islocated downstream of the third integration mechanism, wherein the thirdcatalytic cracking unit is located downstream of the third hydrotreatingunit, wherein the third fractionator is located downstream of the thirdcatalytic cracking unit; (iv) a fourth hydrotreating unit, a fourthhydrocracking unit, and a fourth fractionator, wherein the fourthhydrotreating unit is located downstream of the fourth integrationmechanism, wherein the fourth hydrocracking unit is located downstreamof the fourth hydrotreating unit, wherein the fourth fractionator islocated downstream of the fourth hydrocracking unit; (v) a fifth thermalcracking unit and a fifth fractionator, wherein the fifth thermalcracking unit is located downstream of the fifth integration mechanismand the fifth fractionator is located downstream of the fifth thermalcracking unit; and/or (vi) a sixth fractionator, a sixth thermalcracking unit, and a sixth hydrotreating unit, wherein the sixthfractionator is located downstream of the sixth integration mechanism,wherein the sixth thermal cracking unit is located downstream of thesixth fractionator, and the sixth hydrotreating unit is locateddownstream of the sixth fractionator.

BRIEF DESCRIPTION OF THE FIGURES

FIG. 1 is a schematic diagram of an integrated biomass conversion andpetroleum refining system according to one embodiment of the presentinvention.

FIG. 2 is an exemplary stability parameter plot showing the change inbio-oil viscosity as a function of time for a high-stability bio-oilhaving a stability parameter (slope of the straight line fit) of 0.1325centipoise per hour.

DETAILED DESCRIPTION

FIG. 1 depicts an integrated system for producing renewable fuels frombiomass and traditional petroleum-derived streams. In particular, FIG. 1illustrates a biomass conversion system 10 that is integrated with apetroleum refinery 12 via an integration system 14. As discussed infurther detail below, the manner in which the biomass conversion system10 is integrated into the petroleum refinery 12 can vary based onvarious properties, such as stability and/or oxygen content, of theproduced bio-oil and the desired product slate from the petroleumrefinery 12. As shown in FIG. 1, integration of the biomass conversionsystem 10 and the petroleum refinery 12 can allow for the commercialscale production of renewable fuels such as, for example, bio-gasoline,bio-jet fuel, bio-diesel, bio-fuel oil, and/or bio-coke.

The biomass conversion system 10 of FIG. 1 includes a biomass source 16for supplying a biomass feedstock to be converted to bio-oil. Thebiomass source 16 can be, for example, a hopper, storage bin, railcar,over-the-road trailer, or any other device that may hold or storebiomass. The biomass supplied by the biomass source 16 can be in theform of solid particles. The biomass particles can be fibrous biomassmaterials comprising cellulose. Examples of suitablecellulose-containing materials include algae, paper waste, and/or cottonlinters. In one embodiment, the biomass particles can comprise alignocellulosic material. Examples of suitable lignocellulosic materialsinclude forestry waste such as wood chips, saw dust, pulping waste, andtree branches; agricultural waste such as corn stover, wheat straw, andbagasse; and/or energy crops such as eucalyptus, switch grass, andcoppice.

As depicted in FIG. 1, the solid biomass particles from the biomasssource 16 can be supplied to a biomass feed system 18. The biomass feedsystem 18 can be any system capable of feeding solid particulate biomassto a biomass conversion reactor 20. While in the biomass feed system 18,the biomass material may undergo a number of pretreatments to facilitatethe subsequent conversion reactions. Such pretreatments may includedrying, roasting, torrefaction, demineralization, steam explosion,mechanical agitation, and/or any combination thereof.

In one embodiment, it may be desirable to combine the biomass with acatalyst in the biomass feed system 18 prior to introducing the biomassinto the biomass conversion reactor 20. Alternatively, the catalyst maybe introduced directly into the biomass conversion reactor 20. Thecatalyst may be fresh and/or regenerated catalyst. The catalyst can, forexample, comprise a solid acid, such as a zeolite. Examples of suitablezeolites include ZSM-5, mordenite, beta, ferrierite, and zeolite-Y.Additionally, the catalyst may comprise a super acid. Examples ofsuitable super acids include sulfonated, phosphated, or fluorinatedforms of zirconia, titania, alumina, silica-alumina, and/or clays. Inanother embodiment, the catalyst may comprise a solid base. Examples ofsuitable solid bases include metal oxides, metal hydroxides, and/ormetal carbonates. In particular, the oxides, hydroxides, and carbonatesof alkali metals, alkaline earth metals, transition metals, and/or rareearth metals are suitable. Other suitable solid bases are layered doublehydroxides, mixed metal oxides, hydrotalcite, clays, and/or combinationsthereof. In yet another embodiment, the catalyst can also comprise analumina, such as alpha-alumina.

It should be noted that solid biomass materials generally containminerals. It is recognized that some of these minerals, such aspotassium carbonate, can have catalytic activity in the conversion ofthe biomass material. Even though these minerals are typically presentduring the chemical conversion taking place in the biomass conversionreactor 20, they are not considered catalysts.

The biomass feed system 18 introduces the biomass feedstock into abiomass conversion reactor 20. In the biomass conversion reactor 20,biomass is subjected to a conversion reaction that produces bio-oil. Thebiomass conversion reactor 20 can facilitate different chemicalconversion reactions such as fast pyrolysis, slow pyrolysis,liquefaction, gasification, or enzymatic conversion. The biomassconversion reactor 20 can be, for example, a fluidized bed reactor, acyclone reactor, an ablative reactor, or a riser reactor.

In one embodiment, the biomass conversion reactor 20 can be a riserreactor and the conversion reaction can be fast pyrolysis. Morespecifically, fast pyrolysis may include catalytic cracking. As usedherein, “pyrolysis” refers to the chemical conversion of biomass causedby heating the feedstock in an atmosphere that is substantially free ofoxygen. In one embodiment, pyrolysis is carried out in the presence ofan inert gas, such as nitrogen, carbon dioxide, and/or steam.Alternatively, pyrolysis can be carried out in the presence of areducing gas, such as hydrogen, carbon monoxide, noncondensable gasesrecycled from the biomass conversion process, and/or any combinationthereof.

Fast pyrolysis is characterized by short residence times and rapidheating of the biomass feedstock. The residence times of the fastpyrolysis reaction can be, for example, less than 10 seconds, less than5 seconds, or less than 2 seconds. Fast pyrolysis may occur attemperatures between 200 and 1,000° C., between 250 and 800° C., orbetween 300 and 600° C.

Referring again to FIG. 1, the conversion effluent 21 exiting thebiomass conversion reactor 20 generally comprises gas, vapors, andsolids. As used herein, the vapors produced during the conversionreaction may interchangeably be referred to as “bio-oil,” which is thecommon name for the vapors when condensed into their liquid state.

In one embodiment of the present invention, the conversion reactioncarried out in the biomass conversion reactor 20 produces a bio-oil ofhigh-stability. Such high-stability bio-oil has a stability parameter ofless than 30 centipoise per hour (cp/h). In certain embodiments, thehigh-stability bio-oil can have an oxygen content of less than 15percent by weight. In another embodiment of the present invention, theconversion reaction carried out in the biomass conversion reactor 20produces a bio-oil of intermediate-stability. Suchintermediate-stability bio-oil has a stability parameter in the range of30 to 75 cp/h. In certain embodiments, the intermediate-stabilitybio-oil can have an oxygen content in the range of 15 to 18 percent byweight. In still another embodiment of the present invention, theconversion reaction carried out in the biomass conversion reactor 20produces a bio-oil of low-stability. Such low-stability bio-oil has astability parameter greater than 75 cp/h. In certain embodiments, thelow-stability bio-oil can have an oxygen content greater than 18 percentby weight.

As used herein, the “stability parameter” of a bio-oil is defined as theslope of a best-fit straight line for a plot of bio-oil viscosity(centipoises) over time (hours), where the plotted viscosity values aredetermined while the bio-oil is aged at 90° C. on samples taken at theonset of aging (time=0 hours), 8 hours from the onset of aging, 24 hoursfrom the onset of aging, and 48 hours from the onset of aging. Only datapoints exhibiting a correlation coefficient greater than 0.9 (R²>0.9)are used to determine the stability parameter.

FIG. 2 provides an exemplary stability parameter plot where the slope ofthe best-fit straight line (i.e., the stability parameter) is 0.135 cp/hand the correlation coefficient (R²) for all four data points (times=0,8, 24, and 48 hours) is 0.9519. Since the stability parameter for thebio-oil tested in FIG. 2 is less than 30 cp/h, the bio-oil would beconsidered a “high-stability bio-oil.”

Although FIG. 1 depicts only one biomass conversion system 10 with asingle biomass conversion reactor 20, certain embodiments of the presentinvention may employ multiple biomass conversion systems or multiplebiomass conversion reactors to convert the same or different biomassfeedstocks into a plurality of individual bio-oil streams havingdifferent stability properties. Two or more of these bio-oil streams ofvarying stability can be simultaneously integrated into the petroleumrefinery 12 in accordance with the integration techniques discussed indetail below.

When fast pyrolysis is carried out in the biomass conversion reactor 20,the conversion effluent 21 generally comprises solid particles of char,ash, and/or spent catalyst. The conversion effluent 21 can be introducedinto a solids separator 22. The solids separator 22 can be anyconventional device capable of separating solids from gas and vaporssuch as, for example, a cyclone separator or a gas filter. The solidsseparator 22 removes a substantial portion of the solids (e.g., spentcatalysts, char, and/or heat carrier solids) from the conversioneffluent 21. The solid particles 23 recovered in the solids separator 22can be introduced into a regenerator 24 for regeneration, typically bycombustion. After regeneration, at least a portion of the hotregenerated solids can be introduced directly into the biomassconversion reactor 20 via line 26. Alternatively or additionally, thehot regenerated solids can be directed via line 28 to the biomass feedsystem 18 for combination with the biomass feedstock prior tointroduction into the biomass conversion reactor 20.

The substantially solids-free fluid stream 30 exiting the solidsseparator 22 can then be introduced into an optional fluids separator32. In one embodiment, it is preferred that the bio-oil entering thefluids separator 32 has not previously been subjected to a deoxygenationprocess such as, for example, hydrotreating. The fluids separator 32 canbe any system capable of separating unwanted fluid components 33 fromthe solids-free fluid stream 30 to provide the desired bio-oil 34. Theidentity of the unwanted fluid components 33 may vary depending on manyfactors; however, common unwanted components may include noncondensablegases and/or water. The unwanted fluid components 33 may also includecomponents, such as certain olefins, that are more valuable asindividual products rather than as renewable feeds to the petroleumrefinery.

As discussed previously, the separated bio-oil 34 is integrated into thepetroleum refinery 12 based on the stability of the bio-oil 34 and thedesired product slate of the refinery 12. In one embodiment, an optionalanalyzer 35 is provided to determine the stability parameter and/or theoxygen content of the bio-oil 34 so that the optimal method ofintegration can be chosen based on the stability parameter and/or theoxygen content of the bio-oil 34 as measured by the analyzer 35.

When the bio-oil 34 exhibits a stability parameter of less than 30 cp/hand/or has an oxygen content of less than 15 weight percent, suchhigh-stability bio-oil is routed through line 36 of the integrationsystem 14. When the bio-oil 34 exhibits a stability parameter in therange of 30 to 75 cp/h and/or has an oxygen content of 15 to 18 weightpercent, such intermediate-stability bio-oil is routed through line 38of the integration system 14. When the bio-oil 34 exhibits a stabilityparameter greater than 75 cp/h and/or has an oxygen content greater than18 weight percent, such low-stability bio-oil is routed through line 40of the integration system 14. The integration system 14 can introducethe bio-oil 34 into the conventional petroleum refinery 12 at one ormore appropriate locations, in the appropriate amount, and under theappropriate conditions so the bio-oil is co-processed with apetroleum-derived stream of the refinery. The petroleum-derived streamwith which the bio-oil 34 is co-processed can be, for example, virgingasoil/diesel, light cycle oil (LCO), light catalytic-cycle oil (LCCO),atmospheric residue (AR), deasphalted oil (DAO), heavy crude oil (HCO),heavy catalytic-cycle oil (HCCO), vacuum gas oil (VGO), and/or vacuumresidue (VR).

When the biomass conversion system 10 produces a high-stability bio-oil,the integration system 14 can direct the high-stability bio-oil to afirst treatment process via lines 36 and 36 a and/or to a secondtreatment process via lines 36 and 36 b.

In the first treatment process, the high-stability bio-oil in line 36 acan be combined with a first conventional petroleum-derived stream “A”of the refinery 12. As used herein, “conventional” is understood toencompass any facility, apparatus, or plant whose purpose and functionis in conjunction with the accepted standards and/or well knownpractices in the relevant art concerning petroleum refining orpetrochemicals production. The amount of the high-stability bio-oilcombined with the first petroleum-derived stream A can be at least 0.01,0.1, 1, or 2 percent and/or not more than 50, 25, 10, or 5 percent byweight of the combined streams. The first petroleum-derived stream A canbe, for example, virgin gasoils/diesel, light cycle oil (LCO), and/orlight conversion-cycle oil (LCCO). The combining of the high-stabilitybio-oil and the first petroleum-derived stream A can take place upstreamof a conventional hydrotreater 42 of the refinery 12. Alternatively, thecombining of the high-stability bio-oil and the first petroleum-derivedstream A can take place within the conventional hydrotreater 42. In oneembodiment, the hydrotreater 42 is a conventional diesel hydrotreatingunit of the petroleum refinery 12. In the hydrotreater 42, the combinedstream is subjected to hydrotreatment to thereby produce a hydrotreatedstream that can then be subjected to fractionation in a firstfractionator 44. Such fractionation can produce one or more of thefollowing renewable fuel products: bio-gasoline, bio-jet fuel,bio-diesel, bio-fuel oil, and/or bio-coke.

In the second treatment process, the high-stability bio-oil in line 36 bcan be combined with a second conventional petroleum-derived stream “B”of the refinery 12. The amount of the high-stability bio-oil combinedwith the second petroleum-derived stream B can be at least 0.01, 0.1, 1,or 2 percent and/or not more than 50, 25, 10, or 5 percent by weight ofthe combined streams. The second petroleum-derived stream B can be, forexample, atmospheric residue (AR), deasphalted oil (DAO), vacuum gas oil(VGO), heavy catalytic-cycle oil (HCCO), and/or vacuum residue (VR). Thecombining of the high-stability bio-oil and the second petroleum-derivedstream B can take place upstream of a conventional catalytic cracker 46of the refinery 12. Alternatively, the combining of the high-stabilitybio-oil and the second petroleum-derived stream B can take place withinthe conventional catalytic cracker 46. In one embodiment, the catalyticcracker 46 is a conventional fluid catalytic cracking (FCC) unit or aconventional resid fluid catalytic cracking (RFCC) unit of the petroleumrefinery 12. In the catalytic cracker 46, the combined stream issubjected to catalytic cracking to thereby produce a catalyticallycracked stream that can then be subjected to fractionation in a secondfractionator 48. Such fractionation can produce one or more of thefollowing renewable fuel products: bio-gasoline, bio-jet fuel,bio-diesel, bio-fuel oil, and/or bio-coke.

When the biomass conversion system 10 produces an intermediate-stabilitybio-oil, the integration system 14 can direct the intermediate-stabilitybio-oil to a third treatment process via lines 38 and 38 a and/or to afourth treatment process via lines 38 and 38 b.

In the third treatment process, the intermediate-stability bio-oil inline 38 a can be combined with a third conventional petroleum-derivedstream “C” of the refinery 12. The amount of the intermediate-stabilitybio-oil combined with the third petroleum-derived stream C can be atleast 0.01, 0.1, 1, or 2 percent and/or not more than 50, 25, 10, or 5percent by weight of the combined streams. The third petroleum-derivedstream C can be, for example, light cycle oil (LCO), and/or lightconversion-cycle oil (LCCO), deasphalted oil (DAO), vacuum gas oil(VGO), and/or heavy catalytic-cycle oil (HCCO). The combining of theintermediate-stability bio-oil and the third petroleum-derived stream Ccan take place upstream of a conventional hydrotreater 50 of therefinery 12. Alternatively, the combining of the intermediate-stabilitybio-oil and the third petroleum-derived stream C can take place withinthe conventional hydrotreater 50. In the hydrotreater 50, the combinedstream is subjected to hydrotreatment to thereby produce a hydrotreatedstream that can then be subjected to catalytic cracking in aconventional catalytic cracker 52 of the refinery 12. In one embodiment,the catalytic cracker 52 is a conventional fluid catalytic cracking(FCC) unit and the hydrotreater 50 located upstream of the catalyticcracker 52 is a conventional FCC-feed pre-treater. The cracked streamexiting the catalytic cracker 52 can then be subjected to fractionationin a third fractionator 54. Such fractionation can produce one or moreof the following renewable fuel products: bio-gasoline, bio jet fuel,bio-diesel, bio-fuel oil, and/or bio-coke.

In the fourth treatment process, the intermediate-stability bio-oil inline 38 b can be combined with a fourth conventional petroleum-derivedstream “D” of the refinery 12. The amount of the intermediate-stabilitybio-oil combined with the fourth petroleum-derived stream D can be atleast 0.01, 0.1, 1, or 2 percent and/or not more than 50, 25, 10, or 5percent by weight of the combined streams. The fourth petroleum-derivedstream D can be, for example, light cycle oil (LCO), and/or lightconversion-cycle oil (LCCO), deasphalted oil (DAO), vacuum gas oil(VGO), and/or heavy catalytic-cycle oil (HCCO). The combining of theintermediate-stability bio-oil and the fourth petroleum-derived stream Dcan take place upstream of a conventional hydrotreater 56 of therefinery 12. Alternatively, the combining of the intermediate-stabilitybio-oil and the fourth petroleum-derived stream D can take place withinthe conventional hydrotreater 56. In the hydrotreater 56, the combinedstream is subjected to hydrotreatment to thereby produce a hydrotreatedstream that can then be subjected to hydrocracking in a conventionalhydrocracker 58 of the refinery 12. In one embodiment, the hydrocracker58 is a conventional hydrocracking unit. The cracked stream exiting thehydrocracker 58 can then be subjected to fractionation in a fourthfractionator 60. Such fractionation can produce one or more of thefollowing renewable fuel products: bio-gasoline, bio jet fuel,bio-diesel, bio-fuel oil, and/or bio-coke.

When the biomass conversion system 10 produces a low-stability bio-oil,the integration system 14 can direct the low-stability bio-oil to afifth treatment process via lines 40 and 40 a and/or to a sixthtreatment process via lines 40 and 40 b.

In the fifth treatment process, the low-stability bio-oil in line 40 acan be combined with a fifth conventional petroleum-derived stream “E”of the refinery 12. The amount of the low-stability bio-oil combinedwith the fifth petroleum-derived stream E can be at least 0.01, 0.1, 1,or 2 percent and/or not more than 50, 25, 10, or 5 percent by weight ofthe combined streams. The fifth petroleum-derived stream E can be, forexample, light cycle oil (LCO), and/or light conversion-cycle oil(LCCO), vacuum residue (VR). The combining of the low-stability bio-oiland the fifth petroleum-derived stream E can take place upstream of aconventional thermal cracker 62 of the refinery 12. Alternatively, thecombining of the low-stability bio-oil and the fifth petroleum-derivedstream E can take place within the conventional thermal cracker 62. Inthe thermal cracker 62, the combined stream is subjected to thermalcracking to thereby produce a cracked stream 64 that is then removedfrom the thermal cracker 62. The cracked stream 64 can then be dividedinto a stabilized cracked stream 64 a and a bio-coke stream 64 b. Thestabilized cracked stream 64 a can then be subjected to fractionation ina fifth fractionator 66, while the bio-coke stream 64 b is removed fromthe system. In one embodiment, the thermal cracker 62 is a conventionalcoker unit. Such fractionation can produce one or more of the followingrenewable fuel products: bio-gasoline, bio jet fuel, bio-diesel,bio-fuel oil, and/or bio-coke.

In the sixth treatment process, the low-stability bio-oil in line 40 bcan be combined with a sixth conventional petroleum-derived stream “F”of the refinery 12. The amount of the low-stability bio-oil combinedwith the sixth petroleum-derived stream F can be at least 0.01, 0.1, 1,or 2 percent and/or not more than 50, 25, 10, or 5 percent by weight ofthe combined streams. The sixth petroleum-derived stream F can be aheavy residual stream such as, for example, light cycle oil (LCO),and/or light conversion-cycle oil (LCCO), atmospheric residuum (AR),and/or deasphalted oil (DAO). The combining of the low-stability bio-oiland the sixth petroleum-derived stream F can take place upstream of asixth fractionator 68 of the refinery 12. Alternatively, the combiningof the low-stability bio-oil and the sixth petroleum-derived stream Fcan take place within the fractionator 68. In one embodiment, the sixthfractionator 68 is a conventional coker fractionator. In thefractionator 68, the combined stream can be subjected to fractionationto thereby produce at least two fractionated streams. One of thefractionated streams (e.g., a bio-distillate fraction) exiting thefractionator 68 can then be subjected to hydrotreatment in a sixthhydrotreater 70 of the refinery 12. Another of the fractionated streamsexiting the fractionator 68 (e.g., a bio-residual fraction) can then besubjected to thermal cracking in a sixth thermal cracker 72 of therefinery 12. In one embodiment, the thermal cracker 72 is a conventionalcoker unit. The hydrotreated stream exiting the hydrotreater 70 can bebio-gasoline, bio jet fuel, bio-diesel, bio-fuel oil, and/or bio-coke,while the cracked stream exiting the thermal cracker 72 can be referredto as bio-coke.

The bio-gasoline, bio jet fuel, bio-diesel, and bio-fuel oil produced bythe method described herein can have boiling ranges that are typical forconventional gasoline, jet fuel, diesel, and fuel oil, respectively.Accordingly, at least 75, 85, or 95 weight percent of the bio-gasolineproduced by the process described herein has a boiling point in therange of 40 to 215° C.; at least 75, 85, or 95 weight percent of the biojet fuel produced by the process described herein has a boiling point inthe range of 175 to 325° C.; at least 75, 85, or 95 weight percent ofthe bio-diesel produced by the process described herein has a boilingpoint in the range of 250 to 350° C.; and at least 75, 85, or 95 weightpercent of the bio-fuel oil produced by the process described herein hasa boiling point in the range of 325 to 600° C.

EXAMPLES Example 1

A 65 g sample of a bio-oil, derived from the thermo-catalytic conversionof biomass and containing 11 wt % oxygen and a stability parameter of0.1 cp/h, was combined with a 35 g quantity of a petroleum-derived LCOstream. Results of the mixing are shown in the Table 1 below. Theboiling point ranges were determined using simulated distillation.

TABLE 1 Petroleum- Bio-oil Derived LCO Mixture Mid-boiling point (° C.)220 276 253 Boiling Point Range (° C.) 70-520 114-420 70-510 OxygenContent (wt %) 10 <0.5 6.5 TAN (mg KOH/g) 7 0.2 4 Wt % boiling below 215C. 53 13 33 Wt % boiling above 325 C. 24 23 24

The data in Table 1 above demonstrates that high stability bio-oil canbe blended with a high proportion of LCO to render a feedstock that canbe processed in conventional diesel HDT, since the high boiling pointfraction is substantially the same as conventional feeds.

Example 2

An 80 g sample of a bio-oil, derived from the thermo-catalyticconversion of biomass and containing 16 wt % oxygen, and a stabilityparameter of 32 cp/h, was combined with a 20 g quantity of apetroleum-derived LCO stream. Results of the mixing are shown in theTable 2 below. The boiling point ranges were determined using simulateddistillation.

TABLE 2 Petroleum- Bio-oil Derived LCO Mixture Mid-boiling point (° C.)226 276 253 Boiling Point Range (° C.) 100-540 114-420 110-515 OxygenContent (wt %) 16 <0.5 12 TAN (mg KOH/g) 23 0.2 15 Wt % boiling below215 C. 44 13 36 Wt % boiling above 325 C. 54 23 54

The data in Table 2 above demonstrates that moderate stability bio-oilcan be blended with a lower proportion of LCO to render a feedstock thatcan be processed in conventional VGO HDT and or FCC units, since thehigh boiling point fraction is substantially the same as that of typicalstreams processed in such units.

The preferred forms of the invention described above are to be used asillustration only, and should not be used in a limiting sense tointerpret the scope of the present invention. Modifications to theexemplary embodiments, set forth above, could be readily made by thoseskilled in the art without departing from the spirit of the presentinvention.

It is the inventors' intent to rely on the Doctrine of Equivalents todetermine and assess the reasonably fair scope of the present inventionas it pertains to any processes and systems not materially departingfrom but outside the literal scope of the invention as set forth in thefollowing claims.

What is claimed is:
 1. A system for producing renewable fuels, saidsystem comprising: a bio-oil production facility comprising a biomassconversion reactor for converting biomass into bio-oil; a petroleumrefinery for refining petroleum products; and an integration system forcombining at least a portion of said bio-oil from said bio-oilproduction facility with one or more petroleum derived streams in saidpetroleum refinery for co-processing therewith, wherein said integrationsystem comprises at least one of a first, second, third, fourth, fifth,and/or sixth integration mechanism for combining at least a portion ofsaid bio-oil with at least one of said petroleum-derived streams,wherein said refinery comprises one or more of the following refiningsystems (i) through (vi)— (i) a first hydrotreating unit and a firstfractionator, wherein said first hydrotreating unit is locateddownstream of said first integration mechanism and said firstfractionator is located downstream of said first hydrotreating unit;(ii) a first catalytic cracking unit and a second fractionator, whereinsaid first catalytic cracking unit is located downstream of said secondintegration mechanism and said second fractionator is located downstreamof said first catalytic cracking unit; (iii) a second hydrotreatingunit, a second catalytic cracking unit, and a third fractionator,wherein said second hydrotreating unit is located downstream of saidthird integration mechanism, wherein said second catalytic cracking unitis located downstream of said second hydrotreating unit, wherein saidthird fractionator is located downstream of said second catalyticcracking unit; (iv) a third hydrotreating unit, a first hydrocrackingunit, and a fourth fractionator, wherein said third hydrotreating unitis located downstream of said fourth integration mechanism, wherein saidfirst hydrocracking unit is located downstream of said thirdhydrotreating unit, wherein said fourth fractionator is locateddownstream of said first hydrocracking unit; (v) a first thermalcracking unit and a fifth fractionator, wherein said first thermalcracking unit is located downstream of said fifth integration mechanismand said fifth fractionator is located downstream of said first thermalcracking unit; and/or (vi) a sixth fractionator, a second thermalcracking unit, and a fourth hydrotreating unit, wherein said sixthfractionator is located downstream of said sixth integration mechanism,wherein said second thermal cracking unit is located downstream of saidsixth fractionator, wherein said fourth hydrotreating unit is locateddownstream of said sixth fractionator.
 2. The system of claim 1 whereinsaid refinery comprises refining system (i), wherein said firsthydrotreating unit is a diesel hydrotreating unit in said petroleumrefinery.
 3. The system of claim 1 wherein said refinery comprisesrefining system (ii), wherein said first catalytic cracking unit is aresid fluid catalytic cracking (RFCC) unit or a fluid catalytic cracking(FCC) unit in said petroleum refinery.
 4. The system of claim 1 whereinsaid refinery comprises refining system (iii), wherein said secondcatalytic cracking unit is a fluid catalytic cracking (FCC) unit andsaid second hydrotreating unit is a FCC-feed pretreater in saidpetroleum refinery.
 5. The system of claim 1 wherein said refinerycomprises refining system (iv), wherein said first hydrocracking unit isa hydrocracker in said petroleum refinery.
 6. The system of claim 1wherein said refinery comprises refining system (v), wherein said firstthermal cracking unit is a conventional coker in said petroleumrefinery.
 7. The system of claim 1 wherein said refinery comprisesrefining system (vi), wherein said sixth fractionator is a conventionalcoker fractionator and said second thermal cracking unit is aconventional coker in said petroleum refinery.